US20090095529A1 - Measurement Ahead of the Drilling Bit by Analysis of Formation Cuttings Using Ultraviolet Light to Detect the Presence of Oil or Gas - Google Patents
Measurement Ahead of the Drilling Bit by Analysis of Formation Cuttings Using Ultraviolet Light to Detect the Presence of Oil or Gas Download PDFInfo
- Publication number
- US20090095529A1 US20090095529A1 US11/863,336 US86333607A US2009095529A1 US 20090095529 A1 US20090095529 A1 US 20090095529A1 US 86333607 A US86333607 A US 86333607A US 2009095529 A1 US2009095529 A1 US 2009095529A1
- Authority
- US
- United States
- Prior art keywords
- drilling fluid
- drill string
- sensor
- drilling
- outside
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 230000015572 biosynthetic process Effects 0.000 title claims abstract description 30
- 238000005259 measurement Methods 0.000 title claims abstract description 25
- 238000005520 cutting process Methods 0.000 title description 18
- 238000005553 drilling Methods 0.000 claims abstract description 110
- 239000012530 fluid Substances 0.000 claims abstract description 83
- 238000009434 installation Methods 0.000 claims abstract description 3
- 238000000034 method Methods 0.000 claims description 20
- 238000005755 formation reaction Methods 0.000 description 25
- 229930195733 hydrocarbon Natural products 0.000 description 7
- 150000002430 hydrocarbons Chemical class 0.000 description 7
- 239000004215 Carbon black (E152) Substances 0.000 description 2
- 230000003190 augmentative effect Effects 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 230000001050 lubricating effect Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 230000035515 penetration Effects 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 230000035939 shock Effects 0.000 description 1
- 230000000087 stabilizing effect Effects 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
- E21B49/005—Testing the nature of borehole walls or the formation by using drilling mud or cutting data
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
- G01N33/24—Earth materials
- G01N33/241—Earth materials for hydrocarbon content
Definitions
- the invention relates to apparatus and methods for determining the nature of formations at the bottom of a wellbore for use in the oil and gas industry. More specifically the invention relates to the use of an ultraviolet fluorescence detector located in the drill string for determining the nature of the formations at the bottom of a wellbore to allow the drilling trajectory to be changed during drilling operations.
- a well is drilled using a rotary drilling tool comprising a tubular drill string with a drill bit mounted at the end.
- a drilling fluid is supplied from the surface into the inside of the tubular drill string and pumped down to the drill bit where it is discharged into the wellbore, returning to the surface via the annular space between the drill string and the wellbore wall.
- the drilling fluid is used for the cooling and lubricating the drill bit and removing material cut away by the drill (cuttings) and for stabilizing the borehole during drilling.
- Information regarding the drilling conditions can be obtained by measuring the properties of the drilling fluid, in particular the properties of the cuttings carried by the drilling fluid returning to the surface.
- One such property that can be measured is the presence of hydrocarbons in the drilling fluid. Detecting hydrocarbon fluorescence in the drilling fluid returning to the surface is known.
- U.S. Pat. No. 5,084,617 and U.S. Pat. No. 4,609,821 disclose detecting the presence of hydrocarbons in the drilling fluid cuttings. However, their analysis is performed once the drilling fluid with cuttings has returned to the surface.
- a problem with these methods is that, as the drilling depths can reach many hundreds of meters deep, there is a delay before the drilling fluid from the bottom of the well reaches the surface to be analysed and therefore the information the analysis it provides may no longer relate to the properties of the formations at the current location of the drill bit.
- MWD measurement-while-drilling
- LWD logging-while-drilling
- U.S. Pat. No. 6,176,323 describes a drilling system with sensors to measure a variety of parameters. This document discloses measuring optical properties of the drilling fluid, using two sensors to determine whether native hydrocarbons are present in the drilling fluid. One sensor determines the properties of the drilling fluid in the drill string and a separate sensor determines the properties of the drilling fluid containing the cuttings returning to the surface.
- GB2389380 describes a drilling system with sensors to determine the nature of the formations at the bottom of the well.
- the document discloses using at least two measuring means.
- One measuring means measures the properties of the drilling fluid inside the drill string and the second measuring means measures the properties of the drilling fluid outside the drill string, which is carrying the cuttings back up to the surface.
- the measuring means may measure electrical impedance, pH, nuclear density or electric voltage to determine the nature of the formations at the bottom of the well.
- the invention proposes using an ultraviolet fluorescence detector that can receive drilling fluid from both inside and outside the drill string and can be located close to the drill bit. If the measurement can be taken close to the drill bit, information on the nature of the drill bit location can be received quickly and its path adjusted if necessary.
- one aspect of the invention provides an apparatus for determining the nature of the formation at the bottom of a wellbore being drilled with a tubular drill string through which drilling fluid is pumped to return the drilling fluid to the surface via the wellbore, the apparatus comprising: a tool body for installation in a drill string with a bore extending therethrough; and a sensor or detector for measuring a property of the drilling fluid in a passageway in the tool body; the passageway being configured to receive drilling fluid from inside the drill string and to receive drilling fluid from outside the drill string such that the drilling fluid can be directed past the sensor so as to enable measurements to be made.
- the sensor is preferably an ultraviolet fluorescence detector.
- the apparatus allows cuttings brought up by the drilling fluid to be examined, for example by using ultraviolet fluorescence, to detect the presence of oil and gas in the formation.
- the drilling fluid from outside the drill string contains the cuttings formed by the drilling process.
- information about the drilled formation can be obtained.
- the tool body comprises a first passageway extending from the outside of the drill string to the detector and a second passageway extending from the inside of the drill string to the detector from which the drilling fluids can flow so as to be diverted past the ultraviolet light detector.
- the ultraviolet light detector comprises a light emitter and a fluorescence detector and a single passageway running past the emitter and detector which can receive drilling fluid obtained from the inside and outside of the drill string.
- the apparatus also comprises a valve that is operable to divert drilling fluid into the detector from either inside the drill string or outside the drill string. This restricts the drilling fluid that flows through the detector to allowing either only drilling fluid from inside the drill string or only drilling fluid outside the drill string to flow through the detector. By diverting drilling fluid from inside the drill string through the ultraviolet light detector the drilling fluid that will not have cuttings in it can be used to normalize the measurement.
- the tool body is located close to the drill bit so that the measurements of the properties for the drilling fluid outside the drill string can be can be made while the drill bit is still substantially in the same location as where the drilling fluid was discharged form the drill bit.
- the drilling fluid flows at several centimeters per second if the measurement of the properties of the drilling fluid inside and outside the drill string are taken close to the drill bit you can receive information regarding the nature of the formations at the location of the drill bit quickly, as the drilling speed is substantially slower than the flow rate of the drilling fluids.
- a second aspect of the invention is a method for determining the nature of the formation at the bottom of a wellbore being drilled with a tubular drill string through which drilling fluid is pumped to return to the surface via the wellbore the drill string comprising an ultraviolet fluorescence detector, the method comprising, directing a portion of a drilling fluid from inside the drill string past the detector and obtaining a first fluorescence measurement; directing a portion of a drilling fluid from outside the drill string past the detector and obtaining a second fluorescence measurement; and using the first and second fluorescence measurements to determine the nature of the formation at the bottom of the wellbore.
- the method comprises using the first fluorescence measurement of the drilling fluid from inside the drill string to normalize the ultraviolet fluorescence detector.
- the method comprises operating a valve to divert drilling fluid from inside the drill string through the detector or to divert the flow of drilling fluid from outside the drill string through the detector.
- the method comprises measuring the fluorescence near the drill bit. This enables information about the nature of the formations at the drill bit to be received quickly.
- FIG. 1 shows a view of a drilling assembly in a wellbore
- FIG. 2 shows a schematic view of a tool body with ultraviolet detector as part of the drill string for determining the nature of the formations around the borehole.
- a drilling assembly comprises a tubular drill string 1 connected to a drill bit 2 .
- drilling fluid 3 is pumped through the tubular of the drill string 1 at a speed of about 1 m/s and is discharged from the drill bit 2 .
- the drilling fluid collects the formation cuttings produced by the drilling at the well bottom and flows back to the surface via the annulus between the drill string 1 and the wall of the bore hole.
- the rate of penetration (ROP) of the drill bit 2 is about 1 m/h.
- an apparatus comprises a fluorescence detector 5 and an ultraviolet light emitter 6 .
- the detector is tuned to detect the presence of hydrocarbon fluorescence.
- the drilling fluid can be supplied to the detector by either passing through a passageway 7 leading from inside the drill string carrying ‘clean’ drilling fluid to the detector or can pass through a passageway 8 leading from the annulus between the drill string and wellbore wall carrying drilling fluid with cuttings 4 .
- the type of drilling fluid that can flow to the detector is controlled by a value 9 that diverts the required drilling fluid into the passageway 10 .
- the drilling fluid 3 is diverted from the inside of the drill string 1 into the passageways 7 and 10 that lead to the ultraviolet detector.
- the ultraviolet light detector will detect the fluorescence of the drilling fluid to provide a baseline value to normalize the measurements.
- a valve 9 is operated to stop drilling fluid 3 from inside the drilling string flowing through the detector and to allow drilling fluid with cuttings 4 from outside the drilling string into the passage 10 .
- the drilling fluid with cuttings 4 flows past the ultraviolet light detector which will detect the fluorescence of the drilling fluid together with any hydrocarbons from the drilled cuttings.
- a differential measurement regarding the presence of hydrocarbons in the drilling fluid is thus obtained and provides information about the nature of the formations at the bottom of the drilling well.
- This data obtained from the detector is transmitted to the ground surface level via a data transmitter and receiver. The data is analysed at the ground surface level and this information can then be provided to the driller to alter the trajectory of the drill if necessary.
- the nature of the formation at the location of the drill bit at the current time can be obtained because the time between the drill bit cutting through a formation and the time at which the nature of the formations can be determined is small and the drill bit will not have not advanced very far.
- the apparatus according to the invention can be placed in the drill string relatively close to the bit. For example, apparatus placed around 50 feet ( ⁇ 15 m) above the bit will ‘see’ cuttings around 15 seconds after they are drilled whereas the tool will not pass the location from which the came for another 15 hours.
- the exact positioning of the apparatus in the drill string may depend on other factors affecting the drill string design.
- the embodiment described above is founds as part of a relatively conventional rotary drilling setup. However, it could just as easily be part of a coiled tubing drilling setup (CTD) or as part of a wireline drilling system that can be used for drilling lateral wells from a main borehole or the like. Also, the fluorescence sensor describe above can be replaced or augmented with sensors for measuring other properties of the drilling fluid, especially properties that change when the cuttings contain oil.
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Health & Medical Sciences (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Mining & Mineral Resources (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Food Science & Technology (AREA)
- Remote Sensing (AREA)
- Geochemistry & Mineralogy (AREA)
- Fluid Mechanics (AREA)
- Medicinal Chemistry (AREA)
- Analytical Chemistry (AREA)
- Biochemistry (AREA)
- General Health & Medical Sciences (AREA)
- General Physics & Mathematics (AREA)
- Immunology (AREA)
- Pathology (AREA)
- Investigating, Analyzing Materials By Fluorescence Or Luminescence (AREA)
- Investigating Or Analyzing Materials By The Use Of Fluid Adsorption Or Reactions (AREA)
Abstract
Description
- 1. Field of the Invention
- The invention relates to apparatus and methods for determining the nature of formations at the bottom of a wellbore for use in the oil and gas industry. More specifically the invention relates to the use of an ultraviolet fluorescence detector located in the drill string for determining the nature of the formations at the bottom of a wellbore to allow the drilling trajectory to be changed during drilling operations.
- 2. Background Art
- When drilling it is important to know the nature of the formations located around the bottom of the well as it is drilled. By knowing the nature of the formations at the drill bit, is it possible to control the position of the drill bit and keep the well trajectory in the reservoir. Generally a well is drilled using a rotary drilling tool comprising a tubular drill string with a drill bit mounted at the end. A drilling fluid is supplied from the surface into the inside of the tubular drill string and pumped down to the drill bit where it is discharged into the wellbore, returning to the surface via the annular space between the drill string and the wellbore wall. The drilling fluid is used for the cooling and lubricating the drill bit and removing material cut away by the drill (cuttings) and for stabilizing the borehole during drilling.
- Information regarding the drilling conditions can be obtained by measuring the properties of the drilling fluid, in particular the properties of the cuttings carried by the drilling fluid returning to the surface. One such property that can be measured is the presence of hydrocarbons in the drilling fluid. Detecting hydrocarbon fluorescence in the drilling fluid returning to the surface is known. Both U.S. Pat. No. 5,084,617 and U.S. Pat. No. 4,609,821 disclose detecting the presence of hydrocarbons in the drilling fluid cuttings. However, their analysis is performed once the drilling fluid with cuttings has returned to the surface. A problem with these methods is that, as the drilling depths can reach many hundreds of meters deep, there is a delay before the drilling fluid from the bottom of the well reaches the surface to be analysed and therefore the information the analysis it provides may no longer relate to the properties of the formations at the current location of the drill bit.
- Being able to know as quickly as possible the nature of the formation at bottom of the wellbore is important so it is possible to alter the direction of the drill bit and enhance oil recovery by accurate well placement.
- As the area where the drill bit can be may be several kilometres away from the surface, to determine what is happening at the area of the drill bit downhole techniques termed ‘measurement-while-drilling’ (MWD) and ‘logging-while-drilling’ (LWD) have been developed. These techniques involve placing sensors in the drill string to measure of variety of parameters which provide information on the nature of the wellbore and drilling process.
- Currently measurements taken in known MWD and LWD techniques still take place some distance away from the drill bit location. Due to the mechanical vibrations and shocks of the drilling process and the lack of space near the drill bit it is difficult to place sensors close to the drill bit to preserve sufficient mechanical integrity. Therefore the measurements taken concern the formations at the level of the measuring devices and not the formations at the end of the drill bit. When the information regarding the properties of the formation reaches the surface, the drill bit can be some distance away from the formation where the measurements were taken.
- U.S. Pat. No. 6,176,323 describes a drilling system with sensors to measure a variety of parameters. This document discloses measuring optical properties of the drilling fluid, using two sensors to determine whether native hydrocarbons are present in the drilling fluid. One sensor determines the properties of the drilling fluid in the drill string and a separate sensor determines the properties of the drilling fluid containing the cuttings returning to the surface.
- GB2389380 describes a drilling system with sensors to determine the nature of the formations at the bottom of the well. The document discloses using at least two measuring means. One measuring means measures the properties of the drilling fluid inside the drill string and the second measuring means measures the properties of the drilling fluid outside the drill string, which is carrying the cuttings back up to the surface. The measuring means may measure electrical impedance, pH, nuclear density or electric voltage to determine the nature of the formations at the bottom of the well.
- The invention proposes using an ultraviolet fluorescence detector that can receive drilling fluid from both inside and outside the drill string and can be located close to the drill bit. If the measurement can be taken close to the drill bit, information on the nature of the drill bit location can be received quickly and its path adjusted if necessary.
- Accordingly one aspect of the invention provides an apparatus for determining the nature of the formation at the bottom of a wellbore being drilled with a tubular drill string through which drilling fluid is pumped to return the drilling fluid to the surface via the wellbore, the apparatus comprising: a tool body for installation in a drill string with a bore extending therethrough; and a sensor or detector for measuring a property of the drilling fluid in a passageway in the tool body; the passageway being configured to receive drilling fluid from inside the drill string and to receive drilling fluid from outside the drill string such that the drilling fluid can be directed past the sensor so as to enable measurements to be made.
- The sensor is preferably an ultraviolet fluorescence detector.
- The apparatus allows cuttings brought up by the drilling fluid to be examined, for example by using ultraviolet fluorescence, to detect the presence of oil and gas in the formation.
- The drilling fluid from outside the drill string contains the cuttings formed by the drilling process. By performing differential measurements of the drilling fluid inside and outside the drill string, information about the drilled formation can be obtained.
- The tool body comprises a first passageway extending from the outside of the drill string to the detector and a second passageway extending from the inside of the drill string to the detector from which the drilling fluids can flow so as to be diverted past the ultraviolet light detector.
- The ultraviolet light detector comprises a light emitter and a fluorescence detector and a single passageway running past the emitter and detector which can receive drilling fluid obtained from the inside and outside of the drill string.
- Preferably the apparatus also comprises a valve that is operable to divert drilling fluid into the detector from either inside the drill string or outside the drill string. This restricts the drilling fluid that flows through the detector to allowing either only drilling fluid from inside the drill string or only drilling fluid outside the drill string to flow through the detector. By diverting drilling fluid from inside the drill string through the ultraviolet light detector the drilling fluid that will not have cuttings in it can be used to normalize the measurement.
- Preferably the tool body is located close to the drill bit so that the measurements of the properties for the drilling fluid outside the drill string can be can be made while the drill bit is still substantially in the same location as where the drilling fluid was discharged form the drill bit. As the drilling fluid flows at several centimeters per second if the measurement of the properties of the drilling fluid inside and outside the drill string are taken close to the drill bit you can receive information regarding the nature of the formations at the location of the drill bit quickly, as the drilling speed is substantially slower than the flow rate of the drilling fluids.
- A second aspect of the invention is a method for determining the nature of the formation at the bottom of a wellbore being drilled with a tubular drill string through which drilling fluid is pumped to return to the surface via the wellbore the drill string comprising an ultraviolet fluorescence detector, the method comprising, directing a portion of a drilling fluid from inside the drill string past the detector and obtaining a first fluorescence measurement; directing a portion of a drilling fluid from outside the drill string past the detector and obtaining a second fluorescence measurement; and using the first and second fluorescence measurements to determine the nature of the formation at the bottom of the wellbore.
- Preferably the method comprises using the first fluorescence measurement of the drilling fluid from inside the drill string to normalize the ultraviolet fluorescence detector. Preferably the method comprises operating a valve to divert drilling fluid from inside the drill string through the detector or to divert the flow of drilling fluid from outside the drill string through the detector.
- In a particularly preferred embodiment the method comprises measuring the fluorescence near the drill bit. This enables information about the nature of the formations at the drill bit to be received quickly.
- It is also preferred the method is preformed using the apparatus as described above.
-
FIG. 1 shows a view of a drilling assembly in a wellbore; and -
FIG. 2 shows a schematic view of a tool body with ultraviolet detector as part of the drill string for determining the nature of the formations around the borehole. - With reference to
FIG. 1 a drilling assembly comprises atubular drill string 1 connected to adrill bit 2. During drilling,drilling fluid 3 is pumped through the tubular of thedrill string 1 at a speed of about 1 m/s and is discharged from thedrill bit 2. The drilling fluid collects the formation cuttings produced by the drilling at the well bottom and flows back to the surface via the annulus between thedrill string 1 and the wall of the bore hole. The rate of penetration (ROP) of thedrill bit 2 is about 1 m/h. - With reference to
FIG. 2 an apparatus according to an embodiment of the invention comprises afluorescence detector 5 and an ultraviolet light emitter 6. The detector is tuned to detect the presence of hydrocarbon fluorescence. The drilling fluid can be supplied to the detector by either passing through apassageway 7 leading from inside the drill string carrying ‘clean’ drilling fluid to the detector or can pass through apassageway 8 leading from the annulus between the drill string and wellbore wall carrying drilling fluid withcuttings 4. The type of drilling fluid that can flow to the detector is controlled by avalue 9 that diverts the required drilling fluid into thepassageway 10. - According to the invention, the
drilling fluid 3 is diverted from the inside of thedrill string 1 into thepassageways valve 9 is operated to stop drilling fluid 3 from inside the drilling string flowing through the detector and to allow drilling fluid withcuttings 4 from outside the drilling string into thepassage 10. The drilling fluid withcuttings 4 flows past the ultraviolet light detector which will detect the fluorescence of the drilling fluid together with any hydrocarbons from the drilled cuttings. A differential measurement regarding the presence of hydrocarbons in the drilling fluid is thus obtained and provides information about the nature of the formations at the bottom of the drilling well. This data obtained from the detector is transmitted to the ground surface level via a data transmitter and receiver. The data is analysed at the ground surface level and this information can then be provided to the driller to alter the trajectory of the drill if necessary. - By locating the tool body containing the ultraviolet detector close to the drill bit the nature of the formation at the location of the drill bit at the current time can be obtained because the time between the drill bit cutting through a formation and the time at which the nature of the formations can be determined is small and the drill bit will not have not advanced very far.
- The apparatus according to the invention can be placed in the drill string relatively close to the bit. For example, apparatus placed around 50 feet (˜15 m) above the bit will ‘see’ cuttings around 15 seconds after they are drilled whereas the tool will not pass the location from which the came for another 15 hours. The exact positioning of the apparatus in the drill string may depend on other factors affecting the drill string design.
- Using only one detector avoids variation in measurements due to different detection responses or variations in measurement geometry.
- Changes may be made while still remaining within the scope of the invention. For example, the embodiment described above is founds as part of a relatively conventional rotary drilling setup. However, it could just as easily be part of a coiled tubing drilling setup (CTD) or as part of a wireline drilling system that can be used for drilling lateral wells from a main borehole or the like. Also, the fluorescence sensor describe above can be replaced or augmented with sensors for measuring other properties of the drilling fluid, especially properties that change when the cuttings contain oil.
Claims (11)
Applications Claiming Priority (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EPEP06291592.1 | 2006-10-09 | ||
EP06291592A EP1911928B1 (en) | 2006-10-09 | 2006-10-09 | Apparatus and method for detecting hydrocarbons in a wellbore during drilling |
EP06291592 | 2006-10-09 |
Publications (2)
Publication Number | Publication Date |
---|---|
US20090095529A1 true US20090095529A1 (en) | 2009-04-16 |
US7832501B2 US7832501B2 (en) | 2010-11-16 |
Family
ID=37735802
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US11/863,336 Expired - Fee Related US7832501B2 (en) | 2006-10-09 | 2007-09-28 | Measurement ahead of the drilling bit by analysis of formation cuttings using ultraviolet light to detect the presence of oil or gas |
Country Status (4)
Country | Link |
---|---|
US (1) | US7832501B2 (en) |
EP (1) | EP1911928B1 (en) |
AT (1) | ATE449235T1 (en) |
DE (1) | DE602006010566D1 (en) |
Cited By (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2011063086A1 (en) * | 2009-11-19 | 2011-05-26 | Halliburton Energy Services, Inc. | Downhole optical radiometry tool |
US20130105148A1 (en) * | 2011-06-13 | 2013-05-02 | Baker Hughes Incorporated | Hydrocarbon detection in annulus of well |
US8885163B2 (en) | 2009-12-23 | 2014-11-11 | Halliburton Energy Services, Inc. | Interferometry-based downhole analysis tool |
Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4297880A (en) * | 1980-02-05 | 1981-11-03 | General Electric Company | Downhole pressure measurements of drilling mud |
US4609821A (en) * | 1983-07-06 | 1986-09-02 | Nl Industries, Inc. | Testing for the presence of native hydrocarbons down a borehole |
US5061849A (en) * | 1988-04-01 | 1991-10-29 | Baker Hughes Incorporated | Externally mounted radioactivity detector for MWD employing radial inline scintillator and photomultiplier tube |
US5084617A (en) * | 1990-05-17 | 1992-01-28 | Conoco Inc. | Fluorescence sensing apparatus for determining presence of native hydrocarbons from drilling mud |
US6176323B1 (en) * | 1997-06-27 | 2001-01-23 | Baker Hughes Incorporated | Drilling systems with sensors for determining properties of drilling fluid downhole |
US20070137293A1 (en) * | 2005-12-19 | 2007-06-21 | Julian Pop | Downhole measurement of formation characteristics while drilling |
Family Cites Families (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3673864A (en) * | 1970-12-14 | 1972-07-04 | Schlumberger Technology Corp | Methods and apparatus for detecting the entry of formation gases into a well bore |
US3872721A (en) * | 1973-02-28 | 1975-03-25 | Exxon Production Research Co | Downhole gas detector system |
US4802143A (en) * | 1986-04-16 | 1989-01-31 | Smith Robert D | Alarm system for measurement while drilling oil wells |
US5469917A (en) * | 1994-12-14 | 1995-11-28 | Wolcott; Duane K. | Use of capillary-membrane sampling device to monitor oil-drilling muds |
FR2839531B1 (en) | 2002-05-13 | 2005-01-21 | Schlumberger Services Petrol | METHOD AND DEVICE FOR DETERMINING THE NATURE OF A HEAD FORMATION OF A DRILLING TOOL |
WO2004003343A1 (en) * | 2002-06-28 | 2004-01-08 | Shell Internationale Research Maatschappij B.V. | System for detecting gas in a wellbore during drilling |
-
2006
- 2006-10-09 DE DE602006010566T patent/DE602006010566D1/en active Active
- 2006-10-09 EP EP06291592A patent/EP1911928B1/en not_active Not-in-force
- 2006-10-09 AT AT06291592T patent/ATE449235T1/en not_active IP Right Cessation
-
2007
- 2007-09-28 US US11/863,336 patent/US7832501B2/en not_active Expired - Fee Related
Patent Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4297880A (en) * | 1980-02-05 | 1981-11-03 | General Electric Company | Downhole pressure measurements of drilling mud |
US4609821A (en) * | 1983-07-06 | 1986-09-02 | Nl Industries, Inc. | Testing for the presence of native hydrocarbons down a borehole |
US5061849A (en) * | 1988-04-01 | 1991-10-29 | Baker Hughes Incorporated | Externally mounted radioactivity detector for MWD employing radial inline scintillator and photomultiplier tube |
US5084617A (en) * | 1990-05-17 | 1992-01-28 | Conoco Inc. | Fluorescence sensing apparatus for determining presence of native hydrocarbons from drilling mud |
US6176323B1 (en) * | 1997-06-27 | 2001-01-23 | Baker Hughes Incorporated | Drilling systems with sensors for determining properties of drilling fluid downhole |
US20070137293A1 (en) * | 2005-12-19 | 2007-06-21 | Julian Pop | Downhole measurement of formation characteristics while drilling |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2011063086A1 (en) * | 2009-11-19 | 2011-05-26 | Halliburton Energy Services, Inc. | Downhole optical radiometry tool |
US9091151B2 (en) | 2009-11-19 | 2015-07-28 | Halliburton Energy Services, Inc. | Downhole optical radiometry tool |
US8885163B2 (en) | 2009-12-23 | 2014-11-11 | Halliburton Energy Services, Inc. | Interferometry-based downhole analysis tool |
US20130105148A1 (en) * | 2011-06-13 | 2013-05-02 | Baker Hughes Incorporated | Hydrocarbon detection in annulus of well |
Also Published As
Publication number | Publication date |
---|---|
ATE449235T1 (en) | 2009-12-15 |
DE602006010566D1 (en) | 2009-12-31 |
US7832501B2 (en) | 2010-11-16 |
EP1911928A1 (en) | 2008-04-16 |
EP1911928B1 (en) | 2009-11-18 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
EP3426891B1 (en) | Estimation of formation properties based on borehole fluid and drilling logs | |
US6585044B2 (en) | Method, system and tool for reservoir evaluation and well testing during drilling operations | |
US8172007B2 (en) | System and method of monitoring flow in a wellbore | |
US9303510B2 (en) | Downhole fluid analysis methods | |
US8245781B2 (en) | Formation fluid sampling | |
CN102037212B (en) | Drilling wells in compartmentalized reservoirs | |
CA2837656A1 (en) | Core and drill bits with integrated optical analyzer | |
CN101421490A (en) | A method and apparatus for ion-selective discrimination of fluids downhole | |
US10378349B2 (en) | Methods of plotting advanced logging information | |
US7302346B2 (en) | Data logging | |
EP1936112A2 (en) | Method, system and tool for reservoir evaluation and well testing during drilling operations | |
US10024755B2 (en) | Systems and methods for sample characterization | |
US7832501B2 (en) | Measurement ahead of the drilling bit by analysis of formation cuttings using ultraviolet light to detect the presence of oil or gas | |
US20230258079A1 (en) | Method and system for determining a lithology of a subterranean formation | |
CA2821899C (en) | Sampling tool with dual flowline architecture | |
WO2018035222A1 (en) | Method for constructing a continuous pvt phase envelope log | |
US20030209364A1 (en) | Method and device for determining the nature of a formation at the head of drilling tool | |
US11661843B2 (en) | Method and system for determining a lithology of a subterranean formation | |
Al-Beaiji et al. | Identification of Water Entry with New Integrated Production Logging Tool in Challenging Horizontal Wells | |
Grief et al. | Petrophysical Evaluation of Thinly Bedded Reservoirs in High Angle/Displacement Development Wells with the NL Recorded Lithology Logging System | |
NO328485B1 (en) | Device and method for estimating relative permeability in a formation by NMR, resistivity and formation testing | |
Firouz et al. | Applicability of New Production Logging Tools in Horizontal and Deviated Wells of One of Iranian Fields |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: SCHLUMBERGER TECHNOLOGY CORPORATION, TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:REZGUI, FADHEL;VANNUFFELEN, STEPHANE;REEL/FRAME:021233/0317 Effective date: 20070926 |
|
FPAY | Fee payment |
Year of fee payment: 4 |
|
FEPP | Fee payment procedure |
Free format text: MAINTENANCE FEE REMINDER MAILED (ORIGINAL EVENT CODE: REM.) |
|
LAPS | Lapse for failure to pay maintenance fees |
Free format text: PATENT EXPIRED FOR FAILURE TO PAY MAINTENANCE FEES (ORIGINAL EVENT CODE: EXP.); ENTITY STATUS OF PATENT OWNER: LARGE ENTITY |
|
STCH | Information on status: patent discontinuation |
Free format text: PATENT EXPIRED DUE TO NONPAYMENT OF MAINTENANCE FEES UNDER 37 CFR 1.362 |
|
FP | Lapsed due to failure to pay maintenance fee |
Effective date: 20181116 |